Method for producing a flow rich in methane and a flow rich in C2+ hydrocarbons, and associated installation

• US 9,823,015 B2
• Filed: 06/23/2015
• Issued: 11/21/2017
• Est. Priority Date: 07/09/2009
• Status: Active Grant

• Current Assignee: Technip France (Technip)
• Original Assignee: Technip France (Technip)
• Inventors: Gahier, Vanessa, Gouriou, Julie, Barthe, Loic, Thiebault, Sandra
• Primary Examiner(s): Pettitt, John F
• Application Number:
  US14/747,417
• Publication Number:
  US 20150292798A1
• Time in Patent Office: 882 Days
• CPC Class Codes: F25J 2200/02 in a single pressure main column system
• CPC Class Codes: F25J 2200/30 using a side column in a single pressure column system
• CPC Class Codes: F25J 2200/50 using multiple (re-)boiler-condensers at different heights of the column
• CPC Class Codes: F25J 2200/76 Refluxing the column with condensed overhead gas being cycled in a quasi-closed loop refrigeration cycle
• CPC Class Codes: F25J 2205/04 in the feed line, i.e. upstream of the fractionation step
• CPC Class Codes: F25J 2210/06 Splitting of the feed stream, e.g. for treating or cooling in different ways
• CPC Class Codes: F25J 2230/24 Multiple compressors or compressor stages in parallel
• CPC Class Codes: F25J 2230/60 the fluid being hydrocarbons or a mixture of hydrocarbons
• CPC Class Codes: F25J 2240/02 Expansion of a process fluid in a work-extracting turbine (i.e. isentropic expansion), e.g. of the feed stream
• CPC Class Codes: F25J 2245/02 Recycle of a stream in general, e.g. a by-pass stream
• CPC Class Codes: F25J 2270/02 Internal refrigeration with liquid vaporising loop
• CPC Class Codes: F25J 2270/04 Internal refrigeration with work-producing gas expansion loop
• CPC Class Codes: F25J 2270/06 with multiple gas expansion loops
• CPC Class Codes: F25J 2270/88 Quasi-closed internal refrigeration or heat pump cycle, if not otherwise provided
• CPC Class Codes: F25J 2290/80 Retrofitting, revamping or debottlenecking of existing plant
• CPC Class Codes: F25J 3/0209 Natural gas or substitute natural gas
• CPC Class Codes: F25J 3/0233 separation of CnHm with 1 carbon atom or more
• CPC Class Codes: F25J 3/0238 separation of CnHm with 2 carbon atoms or more

Abstract

This method envisions cooling the supply flow in a first heat exchanger, separation in a first separation flask in order to produce a light upper flow and a heavy lower flow and dividing the light upper flow into a supply fraction of a dynamic pressure reduction turbine and a supply fraction of a first distillation column. A cooled reflux flow is formed from an effluent from a dynamic pressure reduction turbine, the portion of the effluent being cooled and at least partially liquefied in a heat exchanger. The cooled reflux flow is introduced from the heat exchanger into the first distillation column.

Claims

1. A method of producing a flow rich in methane and a flow rich in C2+ hydrocarbons from a supply flow containing hydrocarbons, the method comprising:

separating the supply flow into a first fraction of the supply flow and at least a second fraction of the supply flow;

introducing the first fraction of the supply flow into a first heat exchanger;

cooling the first fraction of the supply flow in the first heat exchanger;

introducing the cooled first fraction of the supply flow into a first separation flask in order to produce a light upper flow and a heavy lower flow;

dividing the light upper flow into a turbine supply fraction and a column supply fraction;

pressure reducing the turbine supply fraction in a first dynamic pressure reduction turbine and introducing at least a portion of the turbine supply fraction subjected to pressure reduction into the first turbine in a middle portion of a first distillation column;

cooling and at least partially condensing the column supply fraction and pressure reducing and introducing at least a portion of the cooled column supply fraction into an upper portion of the first distillation column;

introducing the heavy lower flow into a second separation flask in order to produce an upper gas fraction and a lower liquid fraction;

pressure reducing the lower liquid fraction and introducing the lower liquid fraction in the middle portion of the first distillation column;

cooling and at least partially condensing the upper gas fraction;

recovering a lower column flow at the bottom of the first distillation column, the flow rich in C₂⁺ hydrocarbons being formed from the lower column flow;

recovering and reheating of an upper column flow rich in methane;

compressing at least a fraction of the upper column flow in at least a first compressor coupled to the first dynamic pressure reduction turbine and in at least a second compressor;

forming the flow rich in methane from the reheated and compressed upper column flow;

removing an extraction flow from the upper column flow;

cooling the extraction flow in a second heat exchanger and introducing the cooled extraction flow into the upper portion of the first distillation column;

introducing at least a portion of the second fraction of the supply flow into a second dynamic pressure reduction turbine, separate from the first dynamic pressure reduction turbine;

forming an effluent from the second dynamic pressure reduction turbine;

cooling and at least partly liquefying at least a portion of the effluent from the second dynamic pressure reduction turbine in a downstream heat exchanger in heat exchange relationship with at least a fraction of the upper column flow, the downstream heat exchanger being separate from the second heat exchanger;

forming a cooled reflux flow from the portion of the effluent cooled in the downstream heat exchanger; and

introducing the cooled reflux flow from the downstream heat exchanger into the first distillation column.

2. The method according to claim 1, wherein an upper gas flow obtained from the portion of the effluent cooled in the downstream heat exchanger is introduced into an auxiliary distillation column, the cooled reflux flow being formed from a lower flow of the auxiliary distillation column.

3. The method according to claim 2, further comprising:

introducing the effluent from the second dynamic pressure reduction turbine into a downstream separation flask in order to form at the top of the downstream separation flask the upper gas flow and at the bottom of the downstream separation flask a third lower liquid flow; and

cooling the upper gas flow in the downstream heat exchanger and introducing the cooled upper gas flow in the auxiliary column.

4. The method according to claim 2, comprising producing an upper auxiliary flow from the auxiliary distillation column and mixing the upper auxiliary flow with the upper column flow rich in methane produced by the first distillation column.

5. The method according to claim 2, wherein at least a portion of the cooled and at least partially condensed upper gas fraction is introduced in the auxiliary distillation column.

6. The method according to claim 2, wherein a first portion of the cooled column supply fraction is introduced in the auxiliary distillation column, a second portion of the cooled column supply fraction being introduced directly into the first distillation column.

7. The method according to claim 1, wherein the portion of the second fraction of the supply flow introduced into the second dynamic pressure reduction turbine is conveyed from a separation point of the supply flow to the second dynamic pressure reduction turbine without passing through any heat exchanger.

8. The method according to claim 7, wherein an entirety of the second fraction of the supply flow is introduced into the second dynamic pressure reduction turbine without cooling between the step of separating the supply flow and the step of introducing the second fraction of the supply flow into the second dynamic pressure reduction turbine.

9. The method according to claim 1, comprising:

removing a secondary compression fraction from the upper column flow rich in methane, before the upper column flow rich in methane is passed into the first compressor;

passing the secondary compression fraction into a third compressor coupled to the second dynamic pressure reduction turbine; and

introducing the compressed secondary compression fraction from the third compressor into the compressed upper column flow, downstream of the first compressor.

10. The method according to claim 1, comprising:

removing a make-up cooling flow from the upper column flow rich in methane or from a flow formed from the upper column flow rich in methane; and

pressure reducing and introducing the make-up cooling flow subjected to pressure reduction into a flow flowing upstream of the first pressure reduction turbine.

11. The method according to claim 1, wherein the second compressor comprises a first compression stage, at least a second compression stage, and a cooler interposed between the first compression stage and the second compression stage, the method comprising:

passing the compressed upper column flow from the first compressor successively into the first compression stage, into the cooler, and then into the second compression stage.

12. The method according to claim 1, comprising pressure reducing and partially vaporizing the heavy lower flow in the first heat exchanger.

13. The method according to claim 1, comprising:

separating a third supply flow fraction from the supply flow,

introducing the third supply flow fraction in an upstream heat exchanger, and

cooling the third supply flow with flow issuing from the downstream heat exchanger.

14. An installation for producing a flow rich in methane and a flow rich in C₂⁺ hydrocarbons from a supply flow containing hydrocarbons, the installation comprising:

a supply flow separator configured to separate the supply flow into a first fraction of the supply flow and at least a second fraction of the supply flow;

a first heat exchanger configured to cool the first fraction of the supply flow;

a first heat exchange introducer configured to introduce the first fraction of the supply flow into the first heat exchanger;

a first separation flask and a first separation flask introducer configured to introduce the cooled first fraction of the supply flow into the first separation flask in order to produce a light upper flow and a heavy lower flow;

a light upper flow divider configured to divide the light upper flow into a turbine supply fraction and a column supply fraction;

a first distillation column;

a turbine supply fraction pressure reducer configured to reduce a pressure of the turbine supply fraction comprising a first dynamic pressure reduction turbine and a first turbine introducer configured to introduce at least a portion of the fraction subjected to pressure reduction into the first turbine in a middle portion of the first distillation column;

a column supply fraction processor configured to cool and at least partially to condense the column supply fraction comprising a second heat exchanger and a cooled column supply fraction pressure reducer configured to reduce pressure of the cooled column supply fraction and to introduce at least a portion of the cooled column supply fraction into an upper portion of the first distillation column;

a second separation flask and a second separation flask introducer configured to introduce the heavy lower flow into the second separation flask in order to produce an upper gas fraction and a lower liquid fraction;

a pressure reducer configured to reduce the lower liquid fraction and a first distillation column introducer configured to introduce into the middle portion of the first distillation column;

an upper gas fraction cooler and condenser unit configured to cool and at least partially to condense the upper gas fraction

a lower column flow recovery unit configured to recover a lower column flow at the bottom of the first distillation column, and a former configured to form the flow rich in C₂⁺ hydrocarbons from the lower column flow;

an upper column flow recovery and reheating unit configured to recover and to reheat an upper column flow rich in methane, at the top of the first distillation column;

a compressor unit configured to compress at least a fraction of the upper column flow comprising at least a first compressor coupled to the first dynamic pressure reduction turbine and at least a second compressor;

a former configured to form the flow rich in methane from the reheated and compressed upper column flow;

a removal unit configured to remove from the upper column flow an extraction flow,

an introducer configured to introduce the extraction flow in a second heat exchanger and the cooled extraction flow into an upper portion of the first distillation column;

a second dynamic pressure reduction turbine separate from the first dynamic pressure reduction turbine;

a second turbine introducer configured to introduce at least a portion of the second fraction of the supply flow into the second dynamic pressure reduction turbine;

an effluent former configured to form an effluent from the second dynamic pressure reduction turbine;

a downstream heat exchanger separate from the second heat exchanger, the downstream heat exchanger being configured to cool and at least partly liquefy at least a portion of the effluent from the dynamic pressure reduction turbine by heat exchange with at least a fraction of a upper column flow;

a cooled reflux flow former configured to form a cooled reflux flow from the portion of the effluent cooled in the downstream heat exchanger;

a reflux introducer configured to introduce the cooled reflux flow from the downstream heat exchanger into the first distillation column.

15. The installation according to claim 14, comprising:

an auxiliary distillation column,

an upper gas flow introducer configured to introduce in the auxiliary distillation column an upper gas flow obtained from the portion of the effluent cooled in the downstream heat exchanger, and

a cooled reflux flow former configured to form the cooled reflux flow from a lower flow of the auxiliary distillation column.